System and Method for Seismic Streamer Control

ABSTRACT

A control system for use in a marine seismic survey is provided. The system may include one or more processors configured to receive a desired position for one or more seismic streamers during the marine seismic survey. The one or more processors may be further configured to determine a current position for the one or more seismic streamers and to adjust a position of a steering device on each streamer, based upon, at least in part, a comparison between the current position of the one or more seismic streamers and the desired position of the one or more seismic streamers.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of U.S. Provisional Applicationhaving Ser. No. 61/828,345, filed May 29, 2013, and is a divisional ofand claims benefit to U.S. patent application Ser. No. 14/288,597 filedon May 28, 2014 that is published as U.S. Patent Application PublicationNo. 2014-0355380, both of which the entire contents are incorporatedherein by reference.

BACKGROUND

Seismic data acquisition may be conducted by towing some number ofstreamer sections behind a vessel. The streamer sections may havevarying types of construction and sensor mounting in the streamer. Datarecorded on these streamers are stored in memory on the towing vessel.

Marine seismic acquisition systems typically include, among other parts,controlled sources generating seismic waves (e.g., pulses) andreceivers, also known as “hydrophones”, recording the waves reflected ateach interface between sub-surface layers. These receivers are embeddedin long cables called streamers which are towed in parallel by seismicvessels, together with other components, thereby making up a streamerspread. Ranging from 4 up to 12 kilometers, the streamers are separatedfrom each other in the cross line direction by the use of deflectorslocated at each end of the spread generating a side force called lift.

It is desired to tow a seismic spread as quickly as safety andefficiency will allow. It is also desirable to tow the spread to coveras much lateral distance as safety and efficiency will allow. Someissues relating to safety are the maximum tension that the spread canwithstand. As the spread is towed faster, drag increases. If tension atany portion of the spread becomes too large for the relevant component,such can break. Also, the distance between streamers (often towed inparallel, but also towed in other configurations such as “fan”configurations) relates to potential for entanglement. Since acts ofnature and errors in calculation and control can make positioning ofstreamer imprecise and reduced at times, a shorter distance between thestreamers can increase risk of entanglement. Similar issues are alsofaced by other components of the spread, including deflectors, tailbuoys, etc.

While these issues have been addressed when towing a spread in astraight line, they have not been addressed when a vessel tows a spreadalong a nonlinear course such as a turn, or in a circular pattern (coilshooting). In those nonlinear towing cases, the outer portion of thespread (with respect to the arc of the turn) will experience anincreased velocity through the water with respect to the interiorportions of the spread. This increased velocity can result in increaseddrag and tension on components of the spread. As noted, the increaseddrag and tension can increase the potential for component failure. Also,the portions of the spread in the interior can move slowly and thereforebecome more susceptible to natural forces such as currents.

One way to mitigate the negative factors experienced by the increasedvelocity of the outer portions of the spread (fast moving) and the innerportions of the spread (slow moving) is by reducing the lateral outwarddistance of the spread, i.e., to narrow the spread. However, doing suchintroduces various issues that have not yet been addressed, such asefficient transition between linear towing into, through and out of aturn with respect to minimizing possibility of entanglement, maximizingspeed and efficiency, and also reducing possibility of equipmentfailure.

Various embodiments herein address a number of these issues.

SUMMARY OF DISCLOSURE

In one implementation, a control system for use in a marine seismicsurvey is provided. The system may include a processor that may receivea desired position for the seismic streamers during the marine seismicsurvey. The processor may determine a current position for the seismicstreamers and may adjust a position of a steering device on eachstreamer, based upon, at least in part, a comparison between the currentposition of the seismic streamers and the desired position of theseismic streamers.

In some implementations, the steering device may be a deflector and theprocessor may control an angle of the deflector to obtain the desiredposition of the streamers. The processor may receive real-time data fromthe streamers. The processor may automatically adjust the position ofthe steering device on each streamer based upon, at least in part, thereal-time data. The control system may include a graphical userinterface that may display the current position and the desired positionof the streamers. The graphical user interface may allow for manual orautomatic control of the control system. The adjustment may be performedin order to obtain a desired separation distance between two of thestreamers. The processor may control a plurality of deflectorsassociated with the streamers.

In another implementation, a method for performing a seismic survey isprovided. The method may include towing a seismic spread including twoouter deflectors and two outer streamers in a substantially straightcourse in a first direction for a predefined distance. After completingtowing along the first distance, the method may include travelingthrough a turn wherein the deflectors each travel along a predefinedcurved path for a radial turn of approximately 180 degrees. After theturn, the method may include traveling along a substantially straightcourse that is substantially parallel to the first course, and towing inan opposite direction to the first direction. The method may furtherinclude predefining a track for each deflector to travel and, using acontrol system, automatically adjusting a position of the deflector tomaintain the deflector on the predefined track wherein the track of eachdeflector being separated by a first lateral distance outside of theturn, and being separated by a second lateral distance that is smallerthan the first distance when in the turn.

In some implementations, the predetermined track between the firstlateral distance and the second lateral distance of the deflectors maybe non-linear. The predetermined track between the first lateraldistance and the second lateral distance of the deflectors may bepartially tapered. A lateral width of the plurality of streamers mayinclude a first lateral distance outside of the turn, and a secondlateral distance that may be smaller than the first lateral distancewhen in the turn. The track of each of the plurality of streamers may bealternated so that one is higher or lower than an adjacent streamer, soas to allow for a tighter grouping of the streamers.

In another implementation, a method for performing a seismic survey isprovided. The method may include towing one or more seismic streamersusing a vessel having a seismic streamer control system associatedtherewith. The method may further include storing a desired position forone or more seismic streamers during the marine seismic survey at thecontrol system and determining a current position for the one or moreseismic streamers. The method may also include automatically adjusting aposition of a steering device on each streamer, based upon, at least inpart, a comparison between the current position of the one or moreseismic streamers and the desired position of the one or more seismicstreamers.

In some implementations, the method may include controlling an angle ofthe deflector to obtain the desired position of the one or morestreamers. The method may further include receiving real-time data fromthe one or more streamers and automatically adjusting the position ofthe steering device on each streamer based upon, at least in part, thereal-time data. The method may also include displaying, at a graphicaluser interface, at least one of the current position and the desiredposition of the one or more streamers. The graphical user interface mayallow for manual or automatic control of the control system. Theadjustment may be performed in order to obtain a desired separationdistance between two of the one or more streamers.

This summary is provided to introduce a selection of concepts that arefurther described below in the detailed description. This summary is notintended to identify key or essential features of the claimed subjectmatter, nor is it intended to be used as an aid in limiting the scope ofthe claimed subject matter.

BRIEF DESCRIPTION OF THE DRAWINGS

Embodiments of the present disclosure are described with reference tothe following figures.

FIG. 1 illustrates an example of a sea vessel that may have a seismicstreamer control system associated therewith in accordance with one ormore embodiments of the present disclosure;

FIG. 2 illustrates an example of a streamer section in accordance withone or more embodiments of the present disclosure;

FIG. 3 illustrates another example of a sea vessel that may have aseismic streamer control system associated therewith in accordance withone or more embodiments of the present disclosure;

FIG. 4 illustrates an example of a deflector in accordance with one ormore embodiments of the present disclosure;

FIG. 5 illustrates an example of a sea vessel that may be in the processof performing a turn in accordance with one or more embodiments of thepresent disclosure;

FIG. 6 is a flow diagram of a process in accordance with one or moreembodiments of the present disclosure;

FIG. 7 illustrates another example of a turning sea vessel that may havea seismic streamer control system associated therewith in accordancewith one or more embodiments of the present disclosure;

FIG. 8 illustrates an example of a computing device that may be used inaccordance with the control system of the present disclosure;

FIG. 9 illustrates an example of a spread prediction system inaccordance with one or more embodiments of the present disclosure;

FIG. 10 illustrates an example of a spread prediction system inaccordance with one or more embodiments of the present disclosure; and

FIG. 11 illustrates an example of a spread prediction system inaccordance with one or more embodiments of the present disclosure.

Like reference symbols in the various drawings may indicate likeelements.

DETAILED DESCRIPTION

The following description concerns a number of embodiments and is meantto provide an understanding of the embodiments. The description is notin any way meant to unduly limit the scope of any present or subsequentrelated claims.

As used here, the terms “above” and “below”, “up” and “down”, “upper”and “lower”, “upwardly” and “downwardly”, and other like termsindicating relative positions above or below a given point or elementare used in this description to more clearly describe some embodimentsof the present disclosure.

Various embodiments provided herein are directed towards a controlsystem for use in a marine seismic survey and related methods. Thesystem may be configured to automatically control the position or pathof travel of one or more seismic streamers during a seismic survey. Thisautomatic control can be based on various parameters such as minimumdistance between the streamers, maximum or minimum lateral position ofthe streamer or spread, minimum velocity of the streamer or spread,maximum velocity of the streamer or spread, and maximum or minimumtension or drag allowed on components of the spread. The system mayinclude one or more processors configured to receive a desired positionfor one or more seismic streamers or components of the spread during themarine seismic survey. The control system may be further configured todetermine a current position for the one or more seismic streamers andto adjust a position of the streamer, velocity through the water ofvarious components of the spread, and related drags and tensions, by wayof a steering device and a comparison between the current position ofthe one or more seismic streamers and the desired position of the one ormore seismic streamers. A detailed description of various methods andsystems used to derive or detect streamer position is included in U.S.Pat. No. 5,668,775 that is incorporated herein by reference in itsentirety. Further, various methods and devices for controlling thestreamer positions are disclosed in U.S. Pat. No. 7,080,607 that isincorporated herein by reference in its entirety.

FIG. 1 illustrates a sea vessel 100 that may include an onboard controlsystem 101 configured to control the position and track of one or moreseismic streamers during a marine survey. Control system 101 may includevarious processors and computing devices configured to communicate (e.g.electrically, wirelessly, etc.) with the seismic streamers and/ordevices associated with the streamers (e.g. deflectors, steeringdevices, sensors, etc.). In some embodiments, this control may occur inreal-time, automatically, and may be based upon data received from oneor more sensors as is discussed in further detail hereinbelow.

Sea vessel 100 may include a reel or spool 104 for deploying a streamer102, which may be a cable-like structure having a number of sensors 103for performing a subterranean survey of a subterranean structure 114below a sea floor 112. A portion of streamer 102, and more particularly,sensors 103, may be deployed in a body of water 108 underneath a seasurface 110. Streamer 102 may be towed by the sea vessel 100 during aseismic operation.

Herein, the term “streamer spread” is intended to cover a streamer orstreamers that is/are towed by sea surface vessel as well as connectedand related equipment such as deflectors, connectors, tail buoys andsteering devices.

In some embodiments, streamer 102 may have a length of 1 kilometer to 12kilometers or more.

Also depicted in FIG. 1 are a number of signal sources 105 that mayproduce signals propagated into the body of water 108 and intosubterranean structure 114. The signals may be reflected from layers insubterranean structure 114, including a resistive body 116 that can beany one of a hydrocarbon-containing reservoir, a fresh water aquifer, aninjection zone, and so forth. Signals reflected from resistive body 116may be propagated upwardly toward sensors 103 for detection by thesensors. Measurement data may be collected by sensors 103, which maystore the measurement data and/or transmit the measurement data back todata storage device 106.

In some embodiments, sensors 103 may be seismic sensors, which may beimplemented with acoustic sensors such as hydrophones, geophones, and/orfiber optic based sensor systems. The signal sources 105 may be seismicsources, such as air guns, marine vibrators and/or explosives. Inanother implementation, the sensors 103 may be electromagnetic (EM)sensors 103, and signal sources 105 may be EM sources that generate EMwaves that are propagated into subterranean structure 114. In someembodiments, the source, which may be towed by the same vessel oranother vessel in proximity, creates an energetic pulse that travelsthrough the ocean and into the subterranean earth formations. This pulsereflects off of the formations in the subterranean earth formations andthe reflected pulse may be detected by the seismic sensors. From thedetected signals, information about the subterranean formation can bedeveloped.

Although not shown in FIG. 1, streamer 102 may further includeadditional sensors (e.g., depth sensors), which may be used to detect aposition of respective sections of streamer 102. In accordance with someembodiments, data from these additional sensors may be sent back tocontrol system 101 and/or data storage device 106 to update informationregarding which sections of streamer 102 are in body of water 108, andwhich sections of streamer 102 are outside the body of water. Specificstreamer location data may also be transmitted/received.

In some embodiments, streamer 102 may include any number, type andconfiguration of sensors. Some of these may include, but are not limitedto, hydrophones, geophones, particle displacement sensors, particlevelocity sensors, accelerometers, pressure gradient sensors, orcombinations thereof.

In some embodiments, streamer 102 may include a multi-componentstreamer, which means that streamer 102 may contain particle motionsensors and pressure sensors. The pressure and particle motion sensorsmay be part of a multi-component sensor unit. Each pressure sensor maybe configured to detect a pressure wavefield, and each particle motionsensor may be configured to detect at least one component of particlemotion that is associated with acoustic signals that are proximate tothe sensor. Examples of particle motions include one or more componentsof a particle displacement, one or more components (inline (x),crossline (y) and vertical (z) components of a particle velocity and oneor more components of a particle acceleration. A more thoroughdiscussion of particle motion sensors may be found in U.S. Patent Pub.2012/0082001, which is incorporated by reference herein in its entirety.A more thorough discussion of streamers may be found in U.S. Pat. No.8,260,555, which is incorporated by reference herein in its entirety.

FIG. 2 shows one particular embodiment depicting an example of a portionof streamer 102, including sections 200A, 200B, and 200C. In thisparticular embodiment, section 200A may include a corresponding sensor103 (such as a seismic sensor) for detecting subterranean features.Sensor 103 may be deployed intermittently (e.g. every other section)throughout streamer 102 in one example. In some embodiments, eachsection may have a corresponding sensor 103 for detecting subterraneanfeatures.

In the ensuing discussion, reference is made to seismic sensors. Note,however, in other implementations, the sensors used for detectingsubterranean features may include any suitable sensors or sensingequipment. Note also that the arrangement in FIG. 2 is an examplearrangement. Different arrangements may be used in otherimplementations. For example, the recording sensors may be within 10'sof meters to the towing vessel Global Navigation Satellite System(“GNSS”) antenna. Streamer 102 may also include additional equipmentthat is not shown in FIG. 2, for example, one or more data storagedevices (e.g. data storage device 106) as is discussed in further detailbelow.

Section 200A may further include a second sensor 202A, which in someembodiments is a depth sensor to detect the depth of the section of thestreamer 102 in the body of water 108. Each of the other sections 200B,200C depicted in FIG. 2 also includes a corresponding second sensor202B, 202C (e.g., depth sensors).

Section 200A may further include steering device 204 to help steerstreamer 102 in the body of water. Steering device 204 may includecontrol surfaces 206 (in the form of blades or wings) that may berotatable about a longitudinal axis of streamer 102 to help steerstreamer 102 in a desired lateral direction. Steering device 204 may beprovided intermittently (e.g. every other section) throughout streamer102.

In some implementations, steering device 204 may include a battery (orother power source) 208 that may be used to power the steering device204. Battery 208 may also be used to power the depth sensor 202A in thesection 200A, as well as depth sensors 202B, 202C in other sections200B, 200C that are relatively close to the section 200A containing thesteering device 204. Power from the battery 208 may be provided overelectrical conductor(s) 210 to the depth sensors 202A, 202B, 202C.Battery 208 may also be configured to power a data storage device (e.g.106, 300, etc.) and in some cases battery 208 may be included within thedata storage device. In alternative implementations, power may beprovided from an alternative source, such as from the sea vessel 100,solar charger associated with a buoy, over an electrical cable 212 (orfiber optic cable) that may be routed through the streamer 102. Toderive power from a fiber optic cable, each sensor 202 would include aconversion circuit to convert optical waves into electrical power. Analternative source of power may include a wave powered generator. A morethorough discussion of wave generated power may be found in U.S. PatentPub. 2009/0147619, which is incorporated by reference herein in itsentirety.

In accordance with some embodiments, depth sensors 202 (202A, 202B, 202Cshown) may be used to detect which sections 200 of streamer 102 aredeployed in the body of water 108. Depth sensors 202 may provide dataregarding whether corresponding sections are in the body of water 108 bycommunicating the data over a communications link (e.g., electrical orfiber optic cable) 212 that is run along the length of the streamer 102to the reel 104 on the sea vessel 100 and/or to data storage device 106.The data provided from depth sensors 202 may be received at and storedwithin data storage device 106. Some or all of the sensors describedherein may communicate with control system 101, 303 to provide real-timelocation information that may be used as the basis for adjusting thepositioning of the streamers, deflectors, etc.

One particular type of marine seismic survey is referred to as a“towed-array” seismic survey. In such a survey, a survey vessel tows anarray of equipment along a straight sail line. The array may include anumber of seismic streamers, in some cases up to eight, twelve, or evensixteen, that can each be several kilometers long. The streamers may bepopulated with a number of instruments, for example, seismic receiverssuch as hydrophones. The array may also include a plurality of seismicsources. As the array is towed along the sail line, the streamers canstraighten and roughly parallel each other.

Referring now to FIG. 3, an embodiment 300 depicting a vessel 302 havinga seismic streamer control system 303 is provided. In some embodiments,the streamers 304 may range from 4 up to 12 kilometers, and may beseparated from each other in the cross line direction by the use ofdeflectors 306 located at each end of the spread generating a side forcecalled lift. Deflectors 306 may be similar to the steering devices shownin FIG. 4 (Deflectors available from the Assignee of the presentapplication are referred to as “Monowings”). FIG. 3 depicts a schematictop view of an example seismic streamer spread. In this particularexample, additional optional small deflectors 308 may be located behinddeflectors 306. These may be used to take the streamers out of the wakeof deflectors 306 to reduce the noise level (These secondary deflectorsare available from the Assignee of the present application and arereferred to as “Miniwings”). Numerous additional components may also beincluded, some of which may include, but are not limited to, lead-in310, guns 312, distance rope 314, and tail buoy 316.

Referring also to FIG. 4, an example of a deflector that may be used inaccordance with the teachings of the present disclosure is provided.Additional information regarding deflector technology may be found inU.S. Pat. No. 7,156,035, which is incorporated by reference in itsentirety.

As noted, the deflector device may be attached to the front portion of aseismic spread and may provide a lateral force to at least one seismicstreamer in the spread. It should be noted that the particular deflectorshown in FIG. 4 is provided merely by way of example as numerousdeflector designs may be used in accordance with the teachings of thepresent disclosure. One design is a deflector having a wing-shapeddeflector body having a remotely-operable pivotal lever or “boom” thatextends rearward from a point near the middle of the trailing edge ofthe wing-shaped body. In use, the wing-shaped deflector body may besuspended beneath a float so as to be completely submerged andpositioned generally vertically in the water, and may be connected tothe towing vessel by means of a tow line, while the tow may be connectedto the end of the boom remote from the wing-shaped body. In operation,as the device is pulled through the water, the wing-shaped body mayproduce a sideways force, or “lift,” which may move the tow laterally.This lift may be varied by adjusting the angle of the boom from thevessel, thus permitting the lateral offset of the tow from the course ofthe vessel to be varied in use.

In some embodiments, in use, rolling stability of the device is providedby the connection to the float, while stability of the device about avertical axis is provided by the drag produced by the tow. Thedeflectors may be large, in some cases 7.5 m high by 2.5 m wide, andweigh several tons. In some cases they may be suspended around 2 m to 8m below the float by means of a fiber rope, and are also provided with asafety chain intended to prevent separation of the float and deflectorwing in the event that the rope breaks.

In some embodiments, the deflector device may be configured for use witha tow line between a towing vessel and a tow in water behind the vessel.As shown in FIG. 4, the deflector device may include a wing-shaped bodyadapted to be coupled to the tow line and shaped to produce in use asideways force which urges the tow line laterally with respect to thedirection of movement of the towing vessel. The deflector device mayfurther include a boom extending rearward from the wing-shaped body, theend of the boom remote from the wing-shaped body being adapted to beconnected to the tow. In some embodiments, the angle between the boomand the wing-shaped body may be remotely adjustable (e.g., via controlsystem 101, 303, etc.) to vary the sideways force produced by thewing-shaped body. The deflector device may further include an elongatefloat member whose underside may be directly connected to the upper endof the wing-shaped body.

According to another deflector design, there is provided a deflectordevice for use with a tow line between a towing vessel and a tow inwater behind the vessel. The device may include a principal wing-shapedbody adapted to be coupled to the tow line and shaped to produce in usea sideways force, which urges the tow line laterally with respect to thedirection of movement of the towing vessel. The device may furtherinclude a boom extending rearward from the principal wing-shaped bodyand an auxiliary wing-shaped body, smaller than the principalwing-shaped body, secured to the end of the boom remote from theprincipal wing-shaped body. The auxiliary wing-shaped body may be shapedso as to produce in use a sideways force in generally the oppositedirection to that produced by the principal wing-shaped body. Anelongate float member whose underside may be directly connected to theupper end of the principal wing-shaped body may also be included.

In this design, the angle between the boom and the principal wing-shapedbody may be remotely adjustable to vary the sideways force produced bythe principal wing-shaped body. Additionally and/or alternatively, theangle between the boom and the principal wing-shaped body may besubstantially fixed. The deflector device may further include remotelyoperable means for varying the angle of the auxiliary wing-shaped bodyto vary the sideways force produced by the auxiliary wing-shaped body,and thereby vary the sideways force produced by the principalwing-shaped body. In either case, the end of the boom remote from theprincipal wing-shaped body may be adapted to be connected to the tow.This remote control may be done electronically and can be done in realtime in connection with central control system 101, 303.

It should be appreciated that the wings can be adjusted by way of motorselectrically or hydraulically, and that numerous wing adjustmentdevices/designs are available in the art. Additionally and/oralternatively, in some embodiments cables may be used to alter the angleof the wing. Any known mechanical connection can be used to adjust thewing angle of the deflector.

In some implementations, the centre of buoyancy of the float member maybe near the trailing edge of the first mentioned (or principal)wing-shaped body, and the angle between the longitudinal axis of thefloat member and the chord of the principal wing-shaped body may beselected such that, in use, the longitudinal axis of the float member isaligned with the towing direction when the chord of the principalwing-shaped member is at its mean or normal angle to the towingdirection.

In some embodiments, the deflector's wing-shaped body may be made fromtitanium, while the float member may be made either from titanium orfrom a fiber-reinforced composite material. However, deflector's of anysuitable material may be used without departing from the scope of thepresent disclosure.

As discussed above, the deflector designs may be used with a marineseismic survey, which may include towing a plurality of laterally spacedseismic deflectors/streamers over an area to be surveyed. The positionof at least one of the deflectors may be controlled, and accordingly thestreamers with the deflector device may be controlled as well.

Seismic survey planning may involve defining straight shooting linesseparated by a line change phase also called a turn as shown in FIG. 5.These turns can be located according to the survey area so that the gunsstart shooting again once vessel 502 engages to a new line. In somecases, it is desired that the entire length of streamers are at leastsubstantially straight before starting shooting, which makes the turnphase require more time. However, it is also possible to have thestreamers in other configurations (e.g., fan mode, etc.) and to follow apredefined path that is not precisely parallel with the streamer, i.e.,the streamer may be angled with respect to the direction of vessel 502as it travels. It should be noted that often times the intended streamerconfiguration (e.g., straight, fan, etc.) may be interrupted by currentsand/or inclement weather, etc. and is not achieved. It is also possibleto shoot through the turns and also to collect data. This can also bedone when following circular paths, which is referred to as coilshooting/surveying.

It is desirable to reduce the time a vessel spends on a survey, andvessel towing speed is a relevant factor. Thus, increasing speed andefficiency in a turn either by increasing the speed at which the vesseltravels though the turn, and/or shortening the distance traveled in theturn by allowing for a shorter turn radius, can be valuable. Anassociated issue therewith is the width of the spread, since theoutermost deflectors/streamers (should the width of the spread remainconstant through the turn) may experience an increased speed though thewater due to the traveling on the outer part of the turn and associatedincrease in drag and tension. In contrast, the streamers on the innerpart of the turn may experience a reduced velocity and can actually goslack, which may be undesirable. The difference in velocities as well asthe additional drag experienced by the outer streamers (sometimesresulting in failure if too great), limit both the radius of the turn aswell as the velocity the vessel can safely achieve.

Accordingly, one approach may involve reducing the lateral spacing ofthe deflectors, the streamers and/or the spread when going through aturn. In some embodiments, this may be achieved by adjusting thedeflectors and the lift the deflectors apply to the spread to establishthe lateral spacing. This can be done by remotely operating thedeflectors to change/control lift and reduce separation. In someembodiments, this may be achieved by changing the angle of attack of thesurfaces of the deflector. As used herein, the phrase “angle of attack”may refer to the angle the “wing” surfaces have when traveling thoughthe water thus creating “lift” and lateral force. However, in some casesgiven the length of the streamers and the size and complexity of thespread, it is not merely a case of changing the deflectors from oneangle (corresponding to wide separation) to another angle (correspondingto narrow separation) to move from a wide lateral spacing for outsidethe turn and through the survey area, to a narrow lateral spacing fortraveling through the turn. Accordingly, the optimization and controltechniques described herein may be used to address these issues.

Referring now to FIG. 6, embodiments of the present disclosure may allowfor automated deflector control using a control system. The method mayinclude towing (602) one or more seismic streamers using a vessel havinga seismic streamer control system associated therewith and storing (604)a desired position for one or more seismic streamers during the marineseismic survey at the control system. The method may further includedetermining (606) a current position for the one or more seismicstreamers and automatically adjusting (608) a position of a steeringdevice on each streamer, based upon, at least in part, a comparisonbetween the current position of the one or more seismic streamers andthe desired position of the one or more seismic streamers.

In some implementations, the steering device may be a deflector asdiscussed herein. Central control system 101, 303 may be configured tocontrol an angle of the deflector to obtain the desired position of theone or more streamers. The control system may be further configured toreceive real-time data from the one or more streamers using any suitablecommunication technique. The control system may be further configured toautomatically adjust the position of the steering device on eachstreamer based upon, at least in part, the real-time data. Theadjustment may be performed in order to obtain a desired separationdistance between streamers. The control system may be further configuredto control a plurality of deflectors on at least one of the one or morestreamers.

In some embodiments, the control system may further include a graphicaluser interface configured to display at least one of the currentposition and the desired position of the one or more streamers. Thisgraphical user interface may be located onboard the vessel oralternatively at a remote location. The graphical user interface mayallow for manual or automatic control of the control system.

In another implementation, a method for performing a seismic survey isprovided. The method may include towing a seismic spread including twoouter deflectors and two outer streamers in a substantially straightcourse in a first direction for a predefined distance. After completingtowing along the first distance, the method may include travelingthrough a turn wherein the deflectors each travel along a predefinedcurved path for a radial turn of approximately 180 degrees. After theturn, the method may include traveling along a substantially straightcourse that is substantially parallel to the first course, and towing inan opposite direction to the first direction. The method may furtherinclude predefining a track for each deflector to travel and, using acontrol system, automatically adjusting a position of the deflector tomaintain the deflector on the predefined track wherein the track of eachdeflector being separated by a first lateral distance outside of theturn, and being separated by a second lateral distance that is smallerthan the first distance when in the turn.

In some implementations, the predetermined track between the firstlateral distance and the second lateral distance of the deflectors maybe non-linear. The predetermined track between the first lateraldistance and the second lateral distance of the deflectors may bepartially tapered. A lateral width of the plurality of streamers mayinclude a first lateral distance outside of the turn, and a secondlateral distance that may be smaller than the first lateral distancewhen in the turn. The track of each of the plurality of streamers may bealternated so that one is higher or lower than an adjacent streamer, soas to allow for a tighter grouping of the streamers.

In some embodiments, central control system 101, 303 may be connected toa motor or other device that controls the angle of attack of thedeflector so that the deflectors go through a predetermined move betweena wide lateral position to a narrow lateral position. The centralcontroller may gradually and at a predefined timing/rate alter the angleof attack of the deflector to gradually change the lift of the deflectoras it moves from a wide tow position to a narrow tow position. Thischange from wide to narrow may be done before the turn or in atransition into the turn as the spread enters the turn. This change fromnarrow to wide may be performed once outside the turn or in a transitionout of the turn as the spread exits the turn. The transition may also bedone once in the turn to allow fast travel of the vessel and spread.

According to another embodiment, tracks of the spread elements (e.g.,streamers, deflectors, etc.) may be predefined ahead of time beforeentrance into the turn, and the deflector angles may be controlled so asto guide the deflectors and the streamers along the predefined tracksthereby moving from a wide lateral spread for straight towing to anarrow spread for traveling through a turn. Additionally and/oralternatively, the tracks may be determined upon entrance to the turn,or determined in transition into the turn. This may be achieved usingthe central control system or another computer navigation system.

In some embodiments, central control system 101, 303 may be configuredto establish a defined track for each deflector as they transition froma wide spread for towing straight while in a survey area, to a narrowspread for entering into and traveling though a turn. The defined trackmay be prepared by the central control system, or may be input to thecentral control system.

In some embodiments, central control system 101, 303 may be a computersystem/processor and may be located on the vessel or in a remotelocation where it communicates with the vessel and the spread. Thecentral control system may be in communication with any number ofdevices, including, but not limited to, the vessel's navigation system,a global navigation system, as well as a spread positioning system thatdetects and determines positions of the streamers and deflectors.

In some embodiments, central control system 101, 303 may be configuredto monitor the location of numerous points along the streamers, thedeflectors and other spread elements. The monitoring of the spread maybe performed using any suitable approach (e.g., using acoustic signalssuch as IRMA, which is used commercially by the Assignee of thisapplication). In some embodiments, portions of the spread that are onthe surface, including, but not limited to, floats attached to thedeflectors or end of the streamers, may be monitored with communicationsystems (e.g. Global Positioning Systems (“GPS”) attached thereto.Further, for any portion of the spread that is on the surface, radar maybe used to monitor the location. Any other commercial method/system fordetermining streamer and spread position may also be used withoutdeparting from the scope of the present disclosure.

Accordingly, using the location information for the spread, the centralcontrol system may be configured to determine if the deflector (or otherspread elements) are in the proper position, or predefined positionalong the track. If the central control system determines that thedeflector position is in need of adjustment, the angle of attack of thedeflector may be updated in real-time remotely to effect that change.Further, the central control system may use velocity information,current information and any other information available, with predictiveprograms/algorithms to predict the present and or future location of thedeflectors and parts of the spread so as to preemptively adjust theangle of the deflectors in anticipation of future and/or currentpositional needs. These adjustments of the deflectors to follow thepredefined tracks may occur in real-time, or adjustments can be made atperiodic time intervals. In some embodiments, the adjustments may occurautomatically or in an automated fashion. These adjustments may helpalleviate need for rapid adjustments of the deflectors by anticipatingfuture positional needs.

Embodiments of the present disclosure may provide the ability tocontinually update the angle of attack of the deflector, and thereforeupdate the lift that may be applied to the lateral force on the spread.This may be beneficial given that oftentimes underwater sea currents mayaffect the location of the deflectors, streamers and the spread. Forexample, in a calm situation where the simple angle of attack for anarrow lateral spacing of the deflectors would lead to the deflectorstraveling along a desired track, in the case of a large sea current suchcould end up in entanglement of the streamers. The central controlsystem may monitor the position of the spread and update the angle ofattack of the deflectors, which may help to alleviate such issues.

In some embodiments, the central control system may be configured tocontrol the deflectors to reduce overshoot of the intended lateralspacing. For example, as a deflector moves between the wide/narrowlateral spacing (position), it may be possible for the momentum to makethe deflector overshoot the desired lateral position. One way tocompensate for this is to update the angle of attack to stabilize thedeflector by rotating the angle of attack opposite to that whichaffected the initial move, in order to stop the deflector at theintended lateral position. This may be beneficial in a case where thetransition between wide/narrow is done with rapidity as increase lateralspeed of the deflector increases the change of overshoot. Also, theability of the central control system to adjust the angle of attack ofthe deflector in real-time may allow for real-time adjustments when thedeflector deviates from the desired lateral position. In this way, thesystem may compensate for overshoot in the direction the deflectortraveled to arrive at the track, but also the other direction oncecompensation against overshoot is put in place.

Referring now to FIG. 7, in some embodiments, the teachings of thepresent disclosure may allow for a gradual move from a wide to a narrowlateral spacing. Accordingly, it may be beneficial to gradually starttransition of the spacing of the deflectors so that the resulting trackis non-linear, where the deflector may move laterally most quickly inthe mid part of the transition and may move more slowly as the deflectorstarts lateral movement and approaches the desired lateral position.This may result in the track being tapered at transition portions, forexample, near the entrance and exit of the turn. At the transition thecontrol system may gradually introduce the forces required tonarrow/widen the lateral spacing of the deflectors. This may help reducethe chance of component failure. This is illustrated in FIG. 7 where avessel 705 travels along a track 706. Deflectors 704 may be connectedwith the vessel by tow connectors that in turn connect with thestreamers 707. It should be noted that the two outermost streamers 707are shown here. It is envisioned that additional streamers are locatedbetween the two outermost streamers 707. Also, additional deflectors canbe used inside the outermost deflectors 108 shown here. The deflectors704 follow a deflector track 708, which in this figure matches thestreamer path since the streamer 707 is attached directly behind thedeflector 704. However, streamers do not need to be connected directlybehind the deflectors 704. The deflector track 708 starts before theturn at a lateral spacing “a.” Once the transition is reached at 700,the lateral spacing between the deflector paths 708 narrows gradually.This path 708 can be non-linear and can be tapered at parts. Once thedeflector path 708 comes out of the transition and to the turn 701 thelateral spacing is “b.” By way of the central control system the widthcan be maintained through the turn. The turn is shown here as beingaround a central point “c” with a radius “x,” but can be other generallyarc “U” type shapes. Also, the lateral spacing “b” can vary and does notneed to be constant through the turn. Upon exit from the turn at 702,the deflector track 708 begins to widen and follow the widening track108. This can again be non-linear and can be tapered at portions. At theend of the transition part 703 the deflector track 708 is again at thelateral spacing “a”. It should be appreciated that similar principals asare applied in embodiments herein for the deflector 704 and theassociated deflector track 708 can be applied to the streamers 107 andan associated streamer track since streamers can be steered laterally.That is, the same or similar central control system that has apredefined track 708 for the deflectors 704 can have a predefined trackfor streamers, and such streamer track can move from being laterallywider before the turn to being laterally narrower in the turn, thetransition from wider to narrower can be non-linear and can be taperedat parts. The lateral steering may be performed using commercialproducts such as those available from the Assignees of this application.

In some embodiments, the streamers may be steered vertically to controltheir vertical position. The height of adjacent streamers to one anothermay be adjusted so that the height of one streamer is higher or lowerthan an adjacent streamer so that the streamers may be moved closertogether in a lateral direction from one another without interfering orbecoming too close. The streamers may also be stacked over and undereach other to allow for further tightening of the spread. This allowsfor a tighter configuration while reducing the change of entanglement.The preceding description is meant to illustrate and help one skilledwith the understanding of various embodiments. It is not mean to undulylimit any present or subsequent claims associated with this application.

According to embodiments, the tracks may not be predefined, and can begenerated in real time based on various parameters such as velocity,drag and tension on the components of the streamer spread. According toother embodiments, predefined tracks can be deviated from automaticallywhen the control system determined that thresholds for velocity, dragand/or tension will be reached.

Referring now to FIG. 8, an embodiment of a control system 800consistent with the teachings of the present disclosure is provided. Asdiscussed above, control system 800 may be located on a vessel (or offthe vessel in a command center) and may be in electrical and/or wirelesscommunication with streamers, sensors, deflectors, etc. Control system800 may receive real-time feedback from these sensors and use thatinformation to control particular aspects of the marine surveyequipment.

Control system 800 may include computing device 850, a processor 852,memory 864, an input/output device such as a display 854, acommunication interface 866, and a transceiver 868, among othercomponents. The device 850 may also be provided with a storage device,such as a microdrive or other device, to provide additional storage.Each of the components 850, 852, 864, 854, 866, and 868, may beinterconnected using various buses, and several of the components may bemounted on a common motherboard or in other manners as appropriate.

Processor 852 may execute instructions within the computing device 850,including instructions stored in the memory 864. The processor may beimplemented as a chipset of chips that include separate and multipleanalog and digital processors. The processor may provide, for example,for coordination of the other components of the device 850, such ascontrol of user interfaces, applications run by device 850, and wirelesscommunication by device 850.

In some embodiments, processor 852 may communicate with a user throughcontrol interface 858 and display interface 856 coupled to a display854. The display 854 may be, for example, a TFT LCD(Thin-Film-Transistor Liquid Crystal Display) or an OLED (Organic LightEmitting Diode) display, or other appropriate display technology. Thedisplay interface 856 may comprise appropriate circuitry for driving thedisplay 854 to present graphical and other information to a user. Thecontrol interface 858 may receive commands from a user and convert themfor submission to the processor 852. In addition, an external interface862 may be provide in communication with processor 852, so as to enablenear area communication of device 850 with other devices. Externalinterface 862 may provide, for example, for wired communication in someimplementations, or for wireless communication in other implementations,and multiple interfaces may also be used.

Accordingly, processor 852 may enable underwater high speedcommunications between the control system and one or more devicesassociated with the streamer or portion of the streamer. In this type ofarrangement, and in addition to those discussed herein, power may besupplied from any suitable power supply. Data may be harvested usingunderwater high speed communication systems (e.g. Bluecomm).

In some embodiments, memory 864 may store information within thecomputing device 850. The memory 864 can be implemented as one or moreof a computer-readable medium or media, a volatile memory unit or units,or a non-volatile memory unit or units. Expansion memory 874 may also beprovided and connected to device 850 through expansion interface 872,which may include, for example, a SIMM (Single In Line Memory Module)card interface. Such expansion memory 874 may provide extra storagespace for device 850, or may also store applications or otherinformation for device 850. Specifically, expansion memory 874 mayinclude instructions to carry out or supplement the processes describedabove, and may include secure information also. Thus, for example,expansion memory 874 may be provide as a security module for device 850,and may be programmed with instructions that permit secure use of device850. In addition, secure applications may be provided via the SIMMcards, along with additional information, such as placing identifyinginformation on the SIMM card in a non-hackable manner.

The memory may include, for example, flash memory and/or NVRAM memory,as discussed below. In one implementation, a computer program product istangibly embodied in an information carrier. The computer programproduct may contain instructions that, when executed, perform one ormore methods, such as those described above. The information carrier maybe a computer- or machine-readable medium, such as the memory 864,expansion memory 874, memory on processor 852, or a propagated signalthat may be received, for example, over transceiver 868 or externalinterface 862.

Device 850 may communicate wirelessly through communication interface566, which may include digital signal processing circuitry.Communication interface 866 may provide for communications under variousmodes or protocols, such as GSM voice calls, SMS, EMS, or MMS speechrecognition, CDMA, TDMA, PDC, WCDMA, CDMA2000, Bluecomm, or GPRS, amongothers. Such communication may occur, for example, throughradio-frequency transceiver 868. In addition, short-range communicationmay occur, such as using a Bluetooth, WiFi, or other such transceiver(not shown). In addition, GPS (Global Positioning System) and/or GNSS(Global Navigation Satellite System) receiver module 870 may provideadditional navigation and location-related wireless data to device 850,which may be used as appropriate by applications running on device 850.

Device 850 may also communicate audibly using audio codec 860, which mayreceive spoken information from a user and convert it to usable digitalinformation. Audio codec 860 may likewise generate audible sound for auser, such as through a speaker, e.g., in a handset of device 850.Various additional and/or alternative components may also be included,such as those that may enable undersea communications.

Referring now to FIGS. 9-11, in some embodiments, the central controlsystem described herein may include a spread prediction system. Thissystem may be configured to make a real-time, time prediction of thespread during towed marine seismic acquisitions and line changes. Thespread prediction system may be configured to predict in real-time thefuture positions of the streamers. The speed and acceleration of anypoint on the streamers may be derived from the position.

In some embodiments, the spread prediction system could be used in orderto reduce the time spent in line changes or infills for example. Bypredicting the position and hence the distances between streamers, anoptimization of the trajectory of the vessel could be made (e.g., areduction of the turn radius in the case of line changes). The riskassociated with streamers tangling could be assessed and mitigated. Theenvironmental conditions affecting the behavior of the spread would beaccounted for based on forecast or past experiences.

In some embodiments, the spread prediction system may utilize learningmachines to predict in time the positions of each streamer. The term“learning machine”, as used herein, may refer to a computer-basedprogram that has the ability to learn without being explicitlyprogrammed. It may be fed with a training set containing pastexperiences. Once the machine is trained, it may be used with unknownsets of data.

During the training phase, the system may use the error between theoutputs it has computed and the outputs it should have produced (e.g.,the experimental positions of the streamers) to understand the linksexisting between the inputs and the outputs.

FIG. 9 provides a general description of an embodiment of a spreadprediction system 900 in the case where the positions of the streamersare the parameters of interest. As shown in the Figure, the trainingmodule 902 may receive a variety of inputs, which may be used todetermine the eventual position of the streamers via the predictionmodule. Environmental conditions may be incorporated into the trainingphase. Some environmental conditions may include, but are not limitedto, vessel speed, turn radius, sea current, wind, etc. IRMA informationand vessel trajectory information may be included in both the training902 and prediction modules 904.

In some embodiments, the spread prediction system may be connected tothe seismic positioning system of the vessel (e.g., the GPS of theboat), and possibly several other navigational and environmental inputs.The use of the spread prediction system may allow for a localoptimization of the vessel trajectory. The vessel best path may berecomputed continuously or at fixed intervals.

Referring also to FIG. 10, an embodiment of the spread prediction system1000 depicting a line change application is provided. In someembodiments, the vessel trajectory may be optimized based on inputs suchas the GPS position of the streamers over time and the distances betweenstreamers to avoid tangling.

In some embodiments, spread prediction system 1002 may receive, inreal-time, the navigation information of each streamer. This informationmay include, but is not limited to, receiver positions from an acousticnetwork, GPS information, compass courses, accelerometer information,vessel headings, etc. In addition, environmental information on currentsand sea-state may be incorporated. In some embodiments, the distancesbetween streamers may be computed based on these receivers' positions.The series of previous distances between streamers and the futurepositions of the vessel may be the inputs of the learning machine. Asdiscussed above, it should be noted that various other types of inputparameters may be used in the spread prediction system depending onoutput sought (e.g., receivers' positions etc.). The parameters of thelearning machines may be optimized using trajectory optimizer 1004. Thisoptimization may be based upon, for example, the time horizon ofprediction, the size of the training set, etc.

Referring now to FIG. 11, an embodiment depicting a system 1100configured to determine a confidence measure of the prediction is shown.In order to increase the accuracy of the prediction, the training phasemay be based on a clustering process where clusters of similar data aregathered. During the training phase, the learning machines may use themost relevant clusters to enhance the prediction. The clustering of thedata may be performed, for example, on data collected in the same seaarea and/or on data just collected. Other clusters of data could begenerated based on non-obvious factors highlighted by using methods suchas Principal Component Analysis or K-mean clustering. In someembodiments, the error of the prediction may be based on comparison withthe IRMA derived geometry, as such, the embodiment of FIG. 11, mayinclude the IPM errors to calculate a total error.

It should be noted that any suitable model may be used to predict thestreamer shape. Some of these may include, but are not limited to, aprediction using a partial differential equations system, a predictionusing state extrapolation (e.g. Kalman filters), a prediction using greybox modeling (e.g. mix between physical model and data driven approach),etc.

In some embodiments, the system may receive any number of inputs to themodel. Some of these may include, but are not limited to, previousgeometries, vessel heading/speed, steering system information (e.g.,Monowings forces, on q-fins, etc.), water current measurements, wavemeasurements (e.g. from Doppler wave radar), non-acoustic measurements,prediction of future sea currents, and/or any combination thereof.

The flowchart and block diagrams in the figures illustrate thearchitecture, functionality, and operation of possible implementationsof systems, methods and computer program products according to variousembodiments of the present disclosure. In this regard, each block in theflowchart or block diagrams may represent a module, segment, or portionof code, which comprises one or more executable instructions forimplementing the specified logical function(s). It should also be notedthat, in some alternative implementations, the functions noted in theblock may occur out of the order noted in the figures. For example, twoblocks shown in succession may, in fact, be executed substantiallyconcurrently, or the blocks may sometimes be executed in the reverseorder, depending upon the functionality involved. It will also be notedthat each block of the block diagrams and/or flowchart illustration, andcombinations of blocks in the block diagrams and/or flowchartillustration, can be implemented by special purpose hardware-basedsystems that perform the specified functions or acts, or combinations ofspecial purpose hardware and computer instructions.

As used in any embodiment described herein, the term “circuitry” maycomprise, for example, singly or in any combination, hardwiredcircuitry, programmable circuitry, state machine circuitry, and/orfirmware that stores instructions executed by programmable circuitry. Itshould be understood at the outset that any of the operations and/oroperative components described in any embodiment or embodiment hereinmay be implemented in software, firmware, hardwired circuitry and/or anycombination thereof.

The terminology used herein is for the purpose of describing particularembodiments and is not intended to be limiting of the disclosure. Asused herein, the singular forms “a”, “an” and “the” are intended toinclude the plural forms as well, unless the context clearly indicatesotherwise. It will be further understood that the terms “comprises”and/or “comprising,” when used in this specification, specify thepresence of stated features, integers, steps, operations, elements,and/or components, but do not preclude the presence or addition of oneor more other features, integers, steps, operations, elements,components, and/or groups thereof.

The corresponding structures, materials, acts, and equivalents of meansor step plus function elements in the claims below are intended toinclude any structure, material, or act for performing the function incombination with other claimed elements as specifically claimed. Thedescription of the present disclosure has been presented for purposes ofillustration and description, but is not intended to be exhaustive orlimited to the disclosure in the form disclosed. Many modifications andvariations will be apparent to those of ordinary skill in the artwithout departing from the scope and spirit of the disclosure. Theembodiment was chosen and described in order to best explain theprinciples of the disclosure and the practical application, and toenable others of ordinary skill in the art to understand the disclosurefor various embodiments with various modifications as are suited to theparticular use contemplated.

Although a few example embodiments have been described in detail above,those skilled in the art will readily appreciate that many modificationsare possible in the example embodiments without materially departingfrom the System and Method for Seismic Streamer control describedherein. Accordingly, such modifications are intended to be includedwithin the scope of this disclosure as defined in the following claims.In the claims, means-plus-function clauses are intended to cover thestructures described herein as performing the recited function and notonly structural equivalents, but also equivalent structures. Thus,although a nail and a screw may not be structural equivalents in that anail employs a cylindrical surface to secure wooden parts together,whereas a screw employs a helical surface, in the environment offastening wooden parts, a nail and a screw may be equivalent structures.It is the express intention of the applicant not to invoke 35 U.S.C.§112, paragraph 6 for any limitations of any of the claims herein,except for those in which the claim expressly uses the words ‘means for’together with an associated function.

Having thus described the disclosure of the present application indetail and by reference to embodiments thereof, it will be apparent thatmodifications and variations are possible without departing from thescope of the disclosure defined in the appended claims.

What is claimed is:
 1. A control system for use in a marine seismicsurvey, comprising: one or more processors configured to receive adesired position for one or more seismic streamers during the marineseismic survey, the one or more processors further configured todetermine a current position for the one or more seismic streamers andto adjust a position of a steering device on each streamer, based upon,at least in part, a comparison between the current position of the oneor more seismic streamers and the desired position of the one or moreseismic streamers.
 2. The control system of claim 1, wherein thesteering device is a deflector and wherein the one or more processorsare configured to control an angle of the deflector to obtain thedesired position of the one or more streamers.
 3. The control system ofclaim 1, wherein the one or more processors are further configured toreceive real-time data from the one or more streamers.
 4. The controlsystem of claim 3, wherein the one or more processors are furtherconfigured to automatically adjust the position of the steering deviceon each streamer based upon, at least in part, the real-time data. 5.The control system of claim 1, further comprising: a graphical userinterface configured to display at least one of the current position andthe desired position of the one or more streamers.
 6. The control systemof claim 5, wherein the graphical user interface allows for manual orautomatic control of the control system.
 7. The control system of claim1, wherein the adjustment is performed in order to obtain a desiredseparation distance between two of the one or more streamers.
 8. Thecontrol system of claim 1, wherein the one or more processors arefurther configured to control a plurality of deflectors on at least oneof the one or more streamers.
 9. A method for performing a seismicsurvey, comprising: towing one or more seismic streamers using a vesselhaving a seismic streamer control system associated therewith; storing adesired position for one or more seismic streamers during the marineseismic survey at the control system; determining a current position forthe one or more seismic streamers; and automatically adjusting aposition of a steering device on each streamer, based upon, at least inpart, a comparison between the current position of the one or moreseismic streamers and the desired position of the one or more seismicstreamers.
 10. The method of claim 9, further comprising: controlling anangle of the deflector to obtain the desired position of the one or morestreamers.
 11. The method of claim 9, further comprising: receivingreal-time data from the one or more streamers.
 12. The method of claim11, further comprising: automatically adjusting the position of thesteering device on each streamer based upon, at least in part, thereal-time data.
 13. The method of claim 9, further comprising:displaying, at a graphical user interface, at least one of the currentposition and the desired position of the one or more streamers.
 14. Themethod of claim 13, wherein the graphical user interface allows formanual or automatic control of the control system.
 15. The method ofclaim 9, wherein the adjustment is performed in order to obtain adesired separation distance between two of the one or more streamers.16. A control system for use in a marine seismic survey, comprising: oneor more processors configured to receive one or more sets of trainingdata that include prior marine seismic survey data, the one or moreprocessors further configured to determine a future position for one ormore seismic streamers during the marine seismic survey, based upon, atleast in part, the training data, the one or more processors furtherconfigured to determine a vessel best path based upon, at least in part,the future position.
 17. The control system of claim 16, wherein the oneor more processors are further configured to receive real-timeinformation relating to the marine seismic survey.
 18. The controlsystem of claim 17, wherein the real-time information includes at leastone of, a receiver position from an acoustic network, GPS information, acompass course, accelerometer information, a vessel heading, andenvironmental information.
 19. A method for use in a marine seismicsurvey, comprising: receiving, at one or more processors, one or moresets of training data that include prior marine seismic survey data;determining a future position for one or more seismic streamers duringthe marine seismic survey, based upon, at least in part, the trainingdata; and determining a vessel best path based upon, at least in part,the future position.
 20. The method of claim 19, further comprising:receiving real-time information relating to the marine seismic survey.21. The method of claim 20, wherein determining the vessel best path isbased upon both the training data that includes prior marine seismicsurvey data and the real-time information.